IEA Sees Coal Holding 55% of China Power Mix as Wind, Solar Grid Limits Bite
China's coal dependence persists despite record renewables buildout, as grid bottlenecks and flexibility retrofits keep thermal generation central through decade's end.
Coal still supplied roughly 55% of Chinese electricity in 2025, even as the country installed more wind and solar capacity than the rest of the world combined, according to IEA analysis. The figure lands as Beijing's latest five-year plan, published this month, simultaneously targets 50% non-hydrocarbon power generation by 2030 while continuing to approve new coal plants at a pace no other nation comes close to matching.3
The split matters for global gas and LNG markets because every percentage point of Chinese power that coal holds is a percentage point that European and Asian buyers must factor into their own fuel competition. Renewables and nuclear are set to reach 50% of the world's power mix by the end of the decade, the IEA said in its Electricity 2026 report, with natural gas also gaining share, but the pace of that transition hinges disproportionately on what happens inside China's grid.1
China's coal consumption stayed flat in 2025, the first year without growth in a decade, per the Energy Institute's Statistical Review of World Energy. Solar generation jumped 40% year-on-year, adding 336.5 terawatt-hours, while wind rose 13% with an additional 133.6 TWh. Yet flat coal demand is not declining coal demand, and the IEA's 55% share estimate still leaves thermal generation as the backbone of the system.4
The contradiction is operational, not accidental. Grid bottlenecks and renewable-linked industrial projects are limiting how much clean power can actually displace coal, according to analysts tracking China's buildout. China is constructing over 500GW of wind and solar, but the transmission and storage infrastructure to absorb that output has not kept pace, which keeps coal plants running longer than the capacity numbers suggest they should.6
Recent monthly data show the mechanism at work. In April, China boosted coal and gas power generation by 3.1% from a year earlier as wind output fell and nuclear plants underwent maintenance. Thermal generation, mostly coal with a small gas component, increased 3.6% between January and April compared to the same period in 2025, even as domestic coal output slipped 1%. Total power generation rose 2.6% in April and 3.3% for the four-month stretch.2
That is the seasonal pattern traders should be watching. When wind underperforms, coal fills the gap immediately, and China's coal fleet has been deliberately prepared for that role. By mid-2024, 360 GW of coal capacity had already been retrofitted for flexibility services, with a full fleet upgrade targeted by 2027, according to the Energy Institute review. Those retrofits let coal ramp up and down faster, making it the shock absorber for variable renewables rather than a baseload complement being phased out.4
The policy arithmetic reinforces the point. China accounted for 78% of all new coal power generation capacity globally in 2025 and represents 86% of coal capacity currently under construction worldwide that is planned to enter service this year. The five-year plan's 50% non-hydrocarbon target by 2030 is explicitly framed as an energy security objective, which means coal retains an official mandate even as renewables scale.3
Between 2019 and 2025, the world spent $1.1 trillion on wind, solar and other alternative energy, with China leading that spending. But the IEA's projection of renewable output growing by about 1,000 TWh annually through 2030, with solar PV alone accounting for over 600 TWh per year, assumes the grid can absorb that generation. Current evidence suggests absorption is the binding constraint, not installation.3,1
Storage is improving but from a small base. Energy storage capacity rose 81% between 2024 and 2025, and electric vehicles surpassed 50% of new car sales for the first time, which shifts demand patterns toward electrification. Yet oil consumption still grew 2.8% in 2025, increasingly driven by the chemicals sector as EVs erode gasoline and diesel demand, a reminder that China's energy transition is happening sector by sector, not all at once.4
For LNG markets, the signal is mixed. JKM front-month traded at $22.08/MMBtu on Thursday (2026-08-20), reflecting persistent Asian demand strength, while ICE Brent front-month sat at $94.30/bbl. But China's gas-fired power generation remains a small share of the thermal mix, and the country's ability to lean on coal when renewables dip means its incremental LNG demand for power generation stays discretionary rather than structural.2
Across the Asia-Pacific region, transport fuel demand has largely stagnated, with regional oil consumption growth slowing to 1.7% annually. India, not China, is now the IEA's projected largest driver of energy-demand growth by 2035, with demand rising over 15 exajoules. China's power story, by contrast, is one of massive renewable buildout coexisting with a coal fleet that refuses to fade.4,5
The unresolved question is whether the 55% coal share starts falling sharply this decade or grinds down slowly. The IEA's global forecast points to coal's share of generation slipping as nuclear, renewables and gas expand, but China's grid bottlenecks, flexibility retrofits and security-driven policy could keep the decline shallower than headline capacity additions imply. The retrofitting of the full coal fleet by 2027 is the timeline to watch; if that upgrade proceeds on schedule, coal is being positioned as a permanent balancing tool, not a temporary bridge.1,4